EP2888437B1 - Système et procédé de séparation de liquide et de gaz à partir d'un mélange polyphasique s'écoulant dans un pipeline - Google Patents

Système et procédé de séparation de liquide et de gaz à partir d'un mélange polyphasique s'écoulant dans un pipeline Download PDF

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Publication number
EP2888437B1
EP2888437B1 EP13752634.9A EP13752634A EP2888437B1 EP 2888437 B1 EP2888437 B1 EP 2888437B1 EP 13752634 A EP13752634 A EP 13752634A EP 2888437 B1 EP2888437 B1 EP 2888437B1
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EP
European Patent Office
Prior art keywords
riser
pipe
liquid
gas
pipeline
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Application number
EP13752634.9A
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German (de)
English (en)
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EP2888437A1 (fr
Inventor
Jørgen GROSS-PETERSEN
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Total E&P Danmark AS
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Maersk Olie og Gas AS
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • E21B43/36—Underwater separating arrangements
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0063—Regulation, control including valves and floats
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D19/00—Degasification of liquids
    • B01D19/0073—Degasification of liquids by a method not covered by groups B01D19/0005 - B01D19/0042
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
    • E21B17/01—Risers
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells

Definitions

  • the invention relates to a system for separating liquid and gas flowing through a multiphase pipeline, said system comprising: A riser having an upper end and a lower end, said riser being at its lower end configured to receive fluid from said multiphase pipeline and having means for delivering of gas at its upper end, said riser further comprising valve means for adjusting the flow at which the gas is delivered through the upper end of said riser.
  • Risers are used to connect subsea pipelines with platform process facilities. Risers for incoming pipelines operating with free gas such as multiphase flow pipelines or wet gas pipelines are known to slug when lifting the liquid from the pipeline up to the riser due to the back-pressure imposed by the riser to the pipeline when lifting the pipeline contents up from the pipeline. This phenomenon is called riser slugging and is a regular flow where alternating liquid or gas flows up through the riser. Riser slugging typically takes place at lower flow rates in the multiphase pipeline and is worse for pipelines sloping down to a riser than for a pipeline sloping up to a riser. It is not always easy to increase the flow rates to solve the slugging as the increased flow rate would require an increased pressure drop over the pipeline which may not be available or which may be very costly to arrange by pumps and or by compressors.
  • Such regular riser slugging is a short frequency phenomenon.
  • Other types of slugging also exist such as terrain-induced slugging due to lateral undulations of the pipeline, throughput changes of a pipeline, slugging during start-up of a pipeline and slugging in connection with pigging operations. The latter three are transient phenomena and are normally handled by throttling of the outflow from the pipeline.
  • Terrain slugging may also occur regularly, but normally have much higher frequencies than riser slugging.
  • Terrain slugging may, as is the case for the transient slugging, only be handled by throttling of the outlet from the pipeline when required.
  • Terrain slugging is less common than riser slugging.
  • Slug flow is troublesome to offshore oil production systems, because it leads to sudden and generally cyclical surges in the flow of liquid (e.g. oil) and gas from the riser pipeline to subsequent processing apparatus located topside of the pipeline, resulting in reduced production, e.g. downstream of the top of the pipeline.
  • liquid e.g. oil
  • gas e.g. gas
  • processing apparatus located topside of the pipeline
  • the method, controller and system may be arranged to prevent the excessive growth of slug flow by choking the flow by varying the aperture of the valve.
  • a pipe to be arranged outside or inside the riser, said pipe having an upper part and a lower part with the lower part being connected to or inserted into the riser, thereby creating a liquid flow path between the riser and the lower part of said pipe having a liquid intake configured to receive liquid from a liquid column in said riser, and said upper end of said pipe being configured to deliver said liquid
  • said pipe further comprising means for adjusting the flow at which said liquid is delivered through the upper end of said pipe; level measuring means adapted for measuring the position of a surface of said liquid column in said riser, and control means capable of controlling said valve means, such that the position of the surface of said liquid column can be adjusted by adjusting the flow at which gas/liquid is delivered via said liquid flow path and through the upper end of said riser and/or said lower part of said pipe.
  • the invention relates to a method as recited in claim 10.
  • figure 1 is shown an example of a system for extraction of gas and oil from a pipeline (4) connected to a caisson or riser (8).
  • the riser (8) is at its upper end connected to means (5, 14) for delivery of gas.
  • the riser is connected to the pipeline (4) across the seabed (20).
  • sea level (21) Above the seabed is shown sea level (21) and deck level (30).
  • the pipeline (4) is a multiphase pipeline in which a mixture of liquid and gas is flowing.
  • the pipeline (4) is provided with a non-return valve (16) and a block valve (17) before entering the riser (8).
  • the pipe (7) inside the riser (8) as shown in figure 1 is the liquid outlet from the riser.
  • the interface (18) between liquid and gas is shown at the bottom of the riser.
  • the flow at which the gas is delivered at the upper end of the riser is controlled by a valve (6).
  • the pipe (7) is arranged inside the riser and is thereby creating a second flow path.
  • the second flow path for delivery of the gas from the top of the riser (14), is running in the space between the pipe (7) and the riser (8).
  • the lower part of the pipe (7) is provided with one or more openings (11), such that liquid can enter the pipe. The liquid can then be lifted up through the pipe (7) by the gas pressure in the riser.
  • the column of liquid inside the riser (8) will rise or fall until its weight is in equilibrium with the pressure differential between the inlet (opening at the bottom end of the pipe) and the top of the riser (the weight of the gas is considered to be negligible).
  • the pressure differential (12) between the liquid outlet and the pressure at the top of the riser and thereby the liquid level in the riser (8) and knowledge of fluid characteristics as specific density, it is thus possible to calculate/estimate the height of the column of liquid.
  • a differential pressure gauge (12) is mounted, so that the pressure between the pipe and the top of the riser can be measured.
  • pressure regulating means and a controlling device it is possible to regulate the pressure in the riser (above the surface of the liquid column) and also to control and regulate the position of the liquid surface.
  • the gas pressure in the riser is regulated through a valve (6) and controlled via a liquid gauge unit (13) inside the riser (8).
  • the riser or caisson
  • the riser can act as a two-phase riser and separate the gas and the liquid when entering.
  • the position of the surface of the column of liquid can also be determined in other ways, such as, for example, by means of ultrasound.
  • the constant low liquid level in the riser (8) does not provide any back-pressure to the pipeline (4), and thereby riser slugs will not be formed, and the multiflow pipeline will flow steadily into the riser.
  • FIG 2 Another embodiment of the invention is shown in figure 2 .
  • the liquid is pumped up from the riser via the pipe (7), while the gas is taken off at the top of the riser (14).
  • the pump may be a submersible pump situated at the lower end of the pipe (9) and being in fluid communication with the liquid separated out at the bottom of the riser (10).
  • the pump may be controlled by a liquid level gauge (e.g. by a radar-type gauge).
  • a differential measurement (12, only shown in figure 1 ) may also be used to control the pump.
  • the liquid lift pump and the instrumentation for operation are installed from the top of the riser, and therefore also retrievable in normal operation.
  • the liquid level gauge is retrievable from the top of the riser through the lubricator (22). The pump may be retrieved through the lubricator while the riser is in operation.
  • the system is, in one embodiment, provided with means for retrieval of a pig.
  • a pig is a commonly known feature which is sent through pipelines to e.g. clean or test the inside, or to act as a barrier.
  • a pig which has passed through the pipeline (4) can be lifted to the surface by use of the arrangement shown in figure 1 and figure 2 .
  • the pipeline (4) is, in the shown embodiment, provided with a downwardly sloping part (15).
  • the sloping part (15) is provided with openings (shown as small dots in the figures) in that part of it, where it is passing through the riser. However, the sloping part of the pipeline continues beyond the riser, such that a pig (not shown) which has been sent through the pipeline (4) will end in this part.
  • the pipeline is furthermore provided with sensors (not shown in the figures), such that it can be verified that the pig has passed the non-return valve 16 and has entered the riser for the pig retrieval (31), and the pig can then be lifted up to the receiver (40) by gas or by crude oil through a pig lift line (1), by which gas (or oil) can be pumped into the pipeline (4) after the non-return valve (17). It is also possible to lift the pig to the surface by increasing the pressure in the riser and therefore also behind the pig.

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Chemical & Material Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Mechanical Engineering (AREA)
  • Pipeline Systems (AREA)
  • Earth Drilling (AREA)

Claims (14)

  1. Système de séparation de liquide et de gaz s'écoulant à travers une canalisation multiphase, ledit système comprenant:
    • une colonne montante (8) ayant une extrémité supérieure (2) et une extrémité inférieure (10), ladite colonne montante étant à son extrémité inférieure configurée pour recevoir un fluide à partir de ladite canalisation multiphase (4) et ayant des moyens pour délivrer (5,6) du gaz à son extrémité supérieure, ladite colonne montante comprenant en outre des moyens de soupape (6) pour régler le débit auquel le gaz est délivré à travers l'extrémité supérieure de ladite colonne montante;
    • un tuyau (7) destiné à être disposé à l'extérieur ou à l'intérieur de la colonne montante, ledit tuyau ayant une partie supérieure (3) et une partie inférieure (9), ladite partie inférieure étant reliée à ou intercalée dans la colonne montante, créant ainsi un trajet d'écoulement de liquide entre la colonne montante et le tuyau (7), ledit tuyau ayant un apport de liquide (11) configuré pour recevoir le liquide à partir d'une colonne de liquide dans ladite colonne montante, et ladite extrémité supérieure (3) dudit tuyau étant configuré pour délivrer ledit liquide, ledit tuyau comprenant en outre des moyens pour régler le débit auquel ledit liquide est délivré à travers l'extrémité supérieure dudit tuyau;
    • caractérisé en ce que le système comprend en outre:
    • des moyens de mesure de niveau (12,13) adaptés pour mesurer la position d'une surface (18) de ladite colonne de liquide dans ladite colonne montante;
    • des moyens de commande aptes à commander lesdits moyens de soupape si bien que la position de la surface de ladite colonne de liquide peut être ajustée en réglant le débit auquel le gaz/liquide est délivré par l'intermédiaire dudit trajet d'écoulement de liquide (7,9,3,11) et à travers le extrémité supérieure de ladite colonne montante (5,6).
  2. Système selon la revendication 1, dans lequel ledit moyen de mesure de niveau comprend un détecteur de niveau nucléonique destiné être positionné dans la colonne montante.
  3. Système selon la revendication 1 ou 2, dans lequel ledit moyen de mesure de niveau comprend au moins un capteur de niveau radar destiné être positionné dans la colonne montante.
  4. Système selon l'une quelconque des revendications 1 à 3, dans lequel le moyen de mesure de niveau comprend: au moins un capteur de niveau à ultrasons positionné à l'intérieur de la colonne montante.
  5. Système selon l'une quelconque des revendications 1 à 4, comprenant:
    • un capteur de pression différentielle capable de mesurer la différence de pression entre la pression dans ledit espace annulaire et ledit tuyau (7);
    • des moyens de commande étant capables de comparer la différence de pression et ainsi calculer la position de la surface de ladite colonne de liquide dans ladite colonne montante.
  6. Système selon l'une quelconque des revendications 1 à 5, comprenant:
    • une première jauge de pression capable de mesurer la pression au niveau de ladite extrémité supérieure dudit tuyau (7);
    • une deuxième jauge de pression étant capable de mesurer la pression dans le trajet d'écoulement de liquide entre la colonne montante et ledit tuyau à l'extrémité supérieure dudit tuyau (2);
    • des moyens de commande étant capables de comparer les pressions mesurées par la première jauge de pression et la deuxième jauge de pression et ainsi estimer la position de la surface de ladite colonne de liquide dans ladite colonne montante.
  7. Système selon l'une quelconque des revendications 1 à 6, comprenant une "ligne de levage (31)" pour forcer un racleur à un récepteur de racleur.
  8. Système selon l'une quelconque des revendications 1 à 7, comprenant en outre une pompe capable d'évacuer le liquide de la colonne montante par l'intermédiaire dudit tuyau.
  9. Système selon la revendication 8, comprenant en outre un moyen de commande capable de régler ladite pompe si bien que la position de la surface de ladite colonne de liquide peut être ajustée en réglant la pompe et un réglage du débit auquel le gaz est délivré par l'intermédiaire dudit espace annulaire et à travers l'extrémité supérieure de ladite colonne montante.
  10. Système selon les revendications 1 à 9, comprenant en outre une colonne montante supplémentaire pour la récupération de racleur.
  11. Procédé de séparation de liquide et de gaz circulant à travers une canalisation multiphase (4) à l'aide d'un tuyau (7) disposé à l'intérieur d'une colonne montante (8), ledit procédé comprenant les étapes consistant à:
    • raccorder ladite colonne montante (8) à ladite canalisation multiphase (4);
    • estimer un niveau supérieur et inférieur préféré d'une colonne de liquide dans ladite colonne montante lors de l'utilisation;
    • introduire un tuyau à l'extérieur ou à l'intérieur de la colonne montante, créant ainsi un espace annulaire entre ladite colonne montante et ledit tuyau, le tuyau (7) s'étendant dans une partie de la colonne montante entre le niveau supérieur et inférieur estimé;
    • mesurer la position d'une surface de la colonne de liquide dans la colonne montante;
    • régler la position de ladite surface en réglant le débit auquel le gaz est délivré par l'intermédiaire dudit espace annulaire et à travers l'extrémité supérieure de ladite colonne montante et/ou ladite section de tuyau.
  12. Procédé selon la revendication 11, comprenant en outre les étapes consistant:
    • au rinçage du fond de la colonne montante par du pétrole brut ou de l'eau et la vidange de la partie supérieure de la colonne montante, ce qui élimine l'accumulation de solides à partir du bas de la colonne montante.
  13. Procédé selon la revendication 11 ou 12, comprenant en outre l'étape consistant:
    • au rinçage de la colonne montante par le gaz pour éliminer les sédiments légèrement flottant à travers le tuyau à l'intérieur ou à l'extérieur de la colonne montante.
  14. Procédé selon les revendications 11 à 13, comprenant l'étape consistant à relier une colonne montante supplémentaire à ladite colonne montante (31), si bien qu'un racleur pompé par ladite canalisation multiphase (4) peut être récupéré via ladite colonne montante supplémentaire.
EP13752634.9A 2012-08-22 2013-08-22 Système et procédé de séparation de liquide et de gaz à partir d'un mélange polyphasique s'écoulant dans un pipeline Active EP2888437B1 (fr)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
US201261692037P 2012-08-22 2012-08-22
DK201270497A DK177716B1 (da) 2012-08-22 2012-08-22 System og fremgangsmåde til separering af væske og gas, der strømmer gennem en multifaserørledning
PCT/EP2013/067485 WO2014029854A1 (fr) 2012-08-22 2013-08-22 Système et procédé pour la séparation de liquide et de gaz circulant dans un pipeline multiphasique

Publications (2)

Publication Number Publication Date
EP2888437A1 EP2888437A1 (fr) 2015-07-01
EP2888437B1 true EP2888437B1 (fr) 2016-12-21

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EP13752634.9A Active EP2888437B1 (fr) 2012-08-22 2013-08-22 Système et procédé de séparation de liquide et de gaz à partir d'un mélange polyphasique s'écoulant dans un pipeline

Country Status (4)

Country Link
US (1) US10364661B2 (fr)
EP (1) EP2888437B1 (fr)
DK (1) DK177716B1 (fr)
WO (1) WO2014029854A1 (fr)

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2523104A (en) * 2014-02-12 2015-08-19 Maersk Olie & Gas Separating system and method for separating liquid and gas flowing through a multiphase pipe
FR3040066B1 (fr) * 2015-08-10 2017-09-29 Technip France Installation sous-marine de separation gaz/liquide

Family Cites Families (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4589434A (en) * 1985-06-10 1986-05-20 Exxon Production Research Co. Method and apparatus to prevent hydrate formation in full wellstream pipelines
BR0109766A (pt) * 2000-03-27 2003-02-04 Rockwater Ltd Tubo ascendente com serviços internos recuperáveis
US6651745B1 (en) * 2002-05-02 2003-11-25 Union Oil Company Of California Subsea riser separator system
DE602005022944D1 (de) * 2004-12-21 2010-09-23 Shell Int Research Verfahren, system, steuerung und rechnerprogrammprodukt zur steuerung des flusses von mehrphasigem fluid
US8453747B2 (en) 2007-05-16 2013-06-04 Statoilhydro Asa Method for liquid control in multiphase fluid pipelines
EP2040047A1 (fr) * 2007-09-20 2009-03-25 Siemens Milltronics Process Instruments Inc. Système multipoint de mesure de niveau
WO2010080040A1 (fr) 2009-01-08 2010-07-15 Aker Subsea As Dispositif de traitement des liquides lors de la compression d'un flux de puits
GB0905375D0 (en) * 2009-03-28 2009-05-13 Univ Cranfield Method, controller and system for controlling the slug flow of a multiphase fluid
WO2011073203A1 (fr) * 2009-12-14 2011-06-23 Shell Internationale Research Maatschappij B.V. Séparation d'effluents à phases multiples de puits sous-marin
US8419833B2 (en) * 2011-02-03 2013-04-16 Haven Technology Apparatus and method for gas-liquid separation

Also Published As

Publication number Publication date
EP2888437A1 (fr) 2015-07-01
US10364661B2 (en) 2019-07-30
DK177716B1 (da) 2014-04-07
WO2014029854A1 (fr) 2014-02-27
US20150233227A1 (en) 2015-08-20
DK201270497A (en) 2014-02-23

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